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Comparative study of methods to estimate hydraulic parametersin the hydraulically undisturbed Opalinus Clay (Switzerland)
Catherine Yu1,2 • Jean-Michel Matray1 • Julio Goncalves2 • David Jaeggi3 •
Werner Grasle4 • Klaus Wieczorek5 • Tobias Vogt6 • Erik Sykes7
Received: 11 March 2016 / Accepted: 17 December 2016 / Published online: 25 February 2017
� The Author(s) 2017. This article is published with open access at Springerlink.com
Abstract The deep borehole (DB) experiment gave the
opportunity to acquire hydraulic parameters in a hydraulically
undisturbed zone of the Opalinus Clay at the Mont Terri rock
laboratory (Switzerland). Three methods were used to esti-
mate hydraulic conductivity and specific storage values of the
OpalinusClay formation and its bounding formations through
the 248 m deep borehole BDB-1: application of a Poiseuille-
type law involving petrophysical measurements, spectral
analysis of pressure time series and in situ hydraulic tests. The
hydraulic conductivity range in theOpalinusClaygivenby the
first method is 2 9 10-14–6 9 10-13 m s-1 for a cementa-
tion factor ranging between 2 and 3. These results show low
vertical variability whereas in situ hydraulic tests suggest
higher values up to 7 9 10-12 m s-1. Core analysis provides
economical estimates of the homogeneous matrix hydraulic
properties but donot account for heterogeneities at larger scale
such aspotential tectonic conductive features. Specific storage
values obtained by spectral analysis are consistent and in the
order of 10-6 m-1, while formulations using phase shift and
gain between pore pressure signals were found to be inap-
propriate to evaluate hydraulic conductivity in the Opalinus
Clay.Thevalues obtainedare globally ingoodagreementwith
the ones obtained previously at the rock laboratory.
Keywords Argillaceous formation � Hydraulic well tests �Poiseuille-type law � Harmonic tidal analysis � Hydraulicconductivity � Specific storage � Nuclear waste disposal
1 Introduction
Based on favourable confining properties, such as low
permeability, strong retention and self-sealing capacities,
clay formations are the preferred host rock option for a
deep geological repository of long-lived, intermediate and
high level radioactive waste in several countries including
France, Belgium and Switzerland. In the latter country, the
Opalinus Clay (OPA) has been selected as a potential host
rock for a disposal facility (Nagra 2002) and has been
studied at the Mont Terri rock laboratory since 1996. The
laboratory is located at a depth of ca. 280 m, in the security
gallery of the A16 Transjurane motorway, which crosses
the Jura Mountains in north-western Switzerland.
The accurate hydraulic characterisation of low perme-
ability formations is of high importance to ensure the safety
of a geological repository. Hydraulic properties can be
estimated by various laboratory and field experiments (Van
Editorial handling: P. Bossart and A. G. Milnes.
This is paper #4 in the Mont Terri Special Issue of the Swiss Journal
of Geosciences (see Bossart et al. 2017, Table 3 and Fig. 7).
& Catherine Yu
1 Institut de Radioprotection et de Surete Nucleaire, 31 Allee
du General Leclerc, 92260 Fontenay-aux-Roses, France
2 Aix Marseille Universite UMR 6635 CEREGE Technopole
Environnement Arbois-Mediterranee, BP80,
13545 Aix-en-Provence Cedex 4, France
3 Federal Office of Topography Swisstopo, Seftigenstrasse 264,
3084 Wabern, Switzerland
4 Federal Institute for Geosciences and Natural Resources
(BGR), Stilleweg 2, 30655 Hannover, Germany
5 Global Research for Safety (GRS), Schwertnergasse 1,
50667 Cologne, Germany
6 National Cooperative for the Disposal of Radioactive Waste
(Nagra), Hardstrasse 73, 5430 Wettingen, Switzerland
7 Nuclear Waste Management Organization, 22 St. Clair Ave.
E., Toronto, ON, Canada
Swiss J Geosci (2017) 110:85–104
DOI 10.1007/s00015-016-0257-9
der Kamp 2001; Yu et al. 2013), including empirical
methods based on the rock matrix properties (Chapuis and
Aubertin 2003), falling head or constant head permeameter
tests in laboratory (Boulin et al. 2012), and in situ field tests
that rely on measurement of pore pressure or water level
changes due to tidal natural loading (Bredehoeft 1967;
Merritt 2004; Jiang et al. 2013) or artificial application of
an hydraulic pressure different from the static formation
pressure (Neuzil 1982; Butler 1998; Mejıas et al. 2009). As
these methods are carried out from sub-millimetre to hec-
tometre investigation scales, scale dependency can affect
the results (Keller et al. 1989; Neuzil 1994).
This paper compares three different techniques to esti-
mate hydraulic properties of the Opalinus Clay: application
of a Poiseuille-type law involving petrophysical measure-
ments, in situ packer tests and spectral analysis of pore
pressure time series.
2 Geological setting
The Opalinus Clay at the Mont Terri site is an overconsoli-
dated claystone of Aalenian-Toarcian age, overlain by 800 m
of Middle to Late Jurassic limestones, marls and shales, and
underlain by 400 m of Early Jurassic to Triassic marls and
limestones, dolomites and anhydrites (Fig. 1). The thickness
of the Opalinus Clay in the Mont Terri anticline varies
between 130 m in the BDB-1 borehole and 160 m at rock
laboratory level, depending on the tectonic contribution. This
corresponds to a sedimentary thickness of about 120 m, when
corrected for tectonic overthrusting. The Opalinus Clay
reached a burial depth of 1350 m about 120 Ma ago during
early Cretaceous, which resulted in a maximum temperature
of 80–90 �C (Mazurek et al. 2006). A period of marine
regression occurred between 100 and 40 Ma, leading to a
subaerial exposure of the top of the Malm limestone. Starting
about 40 Ma, the rifting of the Rhine Graben affected
Northern Switzerland, resulting in considerable subsidence of
the area in themid-Tertiary, which brought the Opalinus Clay
sequence back to about 500 m depth. Two sea invasions into
theMont Terri area took place during Priabonian (37–34 Ma)
and during theRupelian (34–28 Ma) (Clauer et al. 2017). Late
Alpine folding during the late Miocene to Pliocene (about
12–3 Ma) formed the Folded Jura. Erosion exposed the core
of theMont Terri anticline towards 2.5 Ma, and allowed fresh
water infiltration to theMiddle Jurassic limestones. Similarly,
infiltration to the Early Jurassic limestoneswould have started
in the Quaternary, around 350 thousand years ago (Pearson
et al. 2003).
Three main facies were identified within the Opalinus
Clay (Blaesi et al. 1991): a shaly facies in the lower part of
the sequence, a thin carbonate-rich sandy facies in the
Fig. 1 Geological cross-section of the Mont Terri anticline. Location
of the rock laboratory is indicated by a white line. The BDB-1 deep
borehole, represented by a thick black line, crosses the lower part of
the Dogger aquifer, the entire Opalinus Clay formation and the upper
part of the Liassic marls (adapted from Nussbaum et al. 2017)
86 C. Yu et al.
middle part of the formation, and a sandy facies inter-
stratified with shaly facies in the upper sequence. The shaly
facies mineral composition includes 27–78% of clay min-
erals (illite, chlorite, kaolinite and illite–smectite mixed
layers), 4–29% of carbonates, 10–32% of quartz, and
accessory feldspars, pyrite and organic matter (Bossart and
Thury 2008).
Several minor tectonic faults and a larger fault zone
called ‘‘Main Fault’’ can be observed in the Opalinus Clay
(Nussbaum et al. 2011). Nagra’s investigations in deep
boreholes at Riniken, Weiach, Schafisheim and Benken
revealed that the tectonically disturbed zones are
hydraulically similar to the undeformed matrix (Johns et al.
1995; Gautschi 2001). Based on permeameter tests and
in situ packer tests, hydraulic conductivity values in tec-
tonically disturbed zones are in the range of 2 9 10-14 to
2 9 10-12 m s-1, and specific storage ranges from
2 9 10-7 to 1.7 9 10-4 m-1 (Marschall et al. 2005).
3 BDB-1 deep borehole
The deep borehole experiment (DB) aims at evaluating the
hydrogeological properties and processes of undisturbed
Opalinus Clay at the Mont Terri rock laboratory. For the
Fig. 2 a Stratigraphic sequence along the BDB-1 borehole; b BDB-1 borehole layout; c Layout of double packer elements (adapted from
Hostettler et al. 2017)
Mont Terri, paper #4: hydraulic parameters in Opalinus Clay 87
first time in this laboratory, a 247.5 m long 45� downwardinclined borehole has been drilled through the Opalinus
Clay and the bounding formations. The stratigraphic
sequence crossed by the borehole is presented in Fig. 2a
and is described in detail in Hostettler et al. (2017). The
borehole was entirely cored for stratigraphic, petrophysi-
cal, mineralogical and geochemical studies. The Opalinus
Clay section was drilled with air as drilling fluid. Drilling
was immediately followed by the installation of a multi-
packer system (Fierz and Rosli 2014) consisting in five
double packer measuring intervals and an interval port
within the Opalinus Clay, a single packer in the Staffelegg
Formation at the bottom of the borehole, and a further
double packer interval isolating the lowermost zone of the
Passwang Formation (Fig. 2b, c). Intervals were equipped
with sensors that enable long term monitoring of pressure
and temperature (Table 1). Pressure sensors are located at
the surface and connected by stainless steel lines to the
interval fluids, whereas temperature sensors are located
downhole inside the intervals.
4 Techniques for hydraulic parameters evaluation
4.1 Petrophysical model
Assuming a plane-parallel geometry, the intrinsic perme-
ability can be computed across an argillaceous formation
using a semi-empirical Poiseuille-type law (Kostek et al.
1992; Pape et al. 1999; Tremosa 2010):
k ¼ b2
3F; ð1Þ
where k is the intrinsic permeability [m2], b is the half-pore
size [m] and F is the formation factor [-], which accounts
for the tortuosity of the porous media and can be deter-
mined using the Archie’s law (Archie 1942):
F ¼ x�m; ð2Þ
where x is the porosity [-] and m is the cementation
factor. The formation factor can also be related to diffusion
parameters (Boving and Grathwohl 2001; Van Loon and
Mibus 2015) or electrical properties (Archie 1942), fol-
lowing Eqs. (3) and (4):
F ¼ Dw
De
; ð3Þ
where Dw is the diffusion coefficient in pure water [m2 s-1]
and De is the effective diffusion coefficient [m2 s-1].
F ¼ R0
Rw
; ð4Þ
where R0 is the rock resistivity [ohm m] saturated with a
brine of resistivity Rw [ohm m].
The half-pore size can be computed from petrophysical
parameters according to the following relation based on a
mass balance equation (Neuzil 2000; Altinier 2006):
b ¼ xð1� xÞqsAs
; ð5Þ
where b is the half-pore size [m], x is the porosity [-], qsis the grain density [g m-3] and As is the specific surface
area [m2 g-1].
Intrinsic permeability and hydraulic conductivity are
linked according to:
K ¼kqf g
lf; ð6Þ
where K is the hydraulic conductivity [m s-1], qf is the
fluid density [kg m-3], g is the gravity acceleration [m s-2]
and lf is the fluid dynamic viscosity [Pa s].
Fluid dynamic viscosity was estimated according to
Mercer et al. (1975):
lf ¼ ð5:38þ 3:8A� 0:26A2Þ � 10�3A; ð7Þ
with
A ¼ T � 150
100; ð8Þ
where lf is the fluid dynamic viscosity [Pa s] and T is the
temperature [�C].The Unesco equation of state (1981) was used to
determine the fluid density as a function of salinity, tem-
perature and pressure.
Determination of petrophysical parameters were per-
formed in laboratory on representative element volume
samples taken from the central part of BDB-1 drillcores.
Porosity and water contents were determined by weighing
before and after oven-drying at 105 �C until mass stabilisa-
tion. Density and degree of saturation were calculated based
on Archimede’s principle after sample immersion into ker-
dane following the experimental protocol first proposed by
Monnier et al. (1973) and later adapted by Matray et al.
(2007) for argillite samples. Grain density was evaluated
using a helium pycnometer (Micromeritics� AccuPyc II
1340) on oven-dried samples and also recalculated from
results of X-Ray diffraction measurements on bulk samples.
Table 1 Specifications of the pressure and temperature sensors
installed in BDB-1 borehole
Sensor type Temperature Pore pressure
Model IST AG PT1000 Keller AG PAA-33X
Validity range -50 to 650 �C 0–50 bars (absolute)
Accuracy ± (0.15 ? 0.002 |T|) �C 0.05% FS
88 C. Yu et al.
4.2 In-situ hydraulic testing experiments
Hydraulic in situ testing in boreholes, also referred as well
testing, is the most common method used in groundwater
and oil industries to acquire the hydraulic properties of
geological formations. Pulse withdrawal tests and constant
rate withdrawal tests were conducted in BDB-1 borehole,
from March 11th to November 16th 2015. During a with-
drawal pulse test, pressure is lowered abruptly by opening
and closing the downhole shut-in valve (Bredehoeft and
Papadopoulos 1980; Neuzil 1982). These tests are pre-
ferred as initial phase because they give an immediate
measurement of the system compressibility and generally
require shorter time frame than pumping tests. Given its
quick hydraulic response, performing more pulse tests on
interval 1 (Staffelegg Formation, Fig. 2b) was possible,
whereas two pulse tests were carried out on each of the
other intervals.
Constant rate withdrawal test parameters such as flow rate
and flow duration must be chosen with caution. In low per-
meability media, high flow rates can lead to desaturation of
the measuring intervals and extreme drops in pressure.
Therefore, a flowmeter able to sustain a very low pumping
rate of 0.3 g h-1 for several days (Bronkhorst� l-flow L01)
was used to test intervals 2 to 7 (Fig. 2b), for which the
hydraulic responses to pulse testing were the slowest.
Interval 1 was tested with a higher flow rate of 5 ml min-1
using a Bronkhorst� Liqui-Flow L10. Experimental setups
for both kind of tests and associated hydraulic responses are
respectively reported in Figs. 3 and 4. Flowmeter failed
during the testing of intervals 2 and 6 and approximatively
two months of pressure recovery were required before per-
forming a second test on these test chambers.
Hydraulic test data were analysed using the well-test
interpretation program nSIGHTS, which was developed by
INTERA for Sandia National Laboratories (Beauheim and
Roberts 2004). The code is based onBarker’s equation (1988),
which describes flow in an n-dimensional space, and does not
restrict to integer dimensions (Beauheim et al. 2004).
Ssoh
ot¼ K
rn�1
o
orrn�1 oh
or
� �; ð9Þ
where Ss is the specific storage coefficient [m-1], h is the
hydraulic head [m], t is the elapsed time [s], K is the
Fig. 3 Experimental set up for: a pulse withdrawal tests; b constant
rate pumping tests performed on BDB-1 borehole (�Solexperts)
Fig. 4 Records of pore pressure responses in the seven intervals of BDB-1 borehole to: a pulse tests; b constant rate withdrawal tests
Mont Terri, paper #4: hydraulic parameters in Opalinus Clay 89
hydraulic conductivity [m s-1], r is the radial distance
from borehole [m], and n is the flow dimension [-].
The flow area is defined as
AðrÞ ¼ b3�n 2pn=2
Cn=2rn�1; ð10Þ
where b is the extent of the flow zone [m], and C is the
gamma function [-].
nSIGHTS is able to take account of borehole inclination
by adjusting parameters such as formation thickness or
capacitive effect. Equations are programmed as functions
of pressure and the code uses unsensitively pressure or
hydraulic head data according to user configuration. Flow
is simulated in saturated conditions under a pressure gra-
dient between the well and the external boundary of the
model following Dupuit conditions. Density effects do not
intervene directly in the equation system, as density is
considered constant in the test interpretation.
Uncertainties associated with the fitted parameters are
evaluated by performing random perturbation analyses.
Plausibility ranges for fitted parameters were defined prior
to the parameter optimisation procedure (Table 2). During
the inverse parameter estimation, nSIGHTS provides best-
fit results within these pre-defined ranges. Optimisation
was performed using a simplex approach. Uncertainties
associated with the fitted parameters are evaluated by
performing random perturbation analyses (not detailed in
this paper).
4.3 Tidal analysis on pore pressure time series
Rotational and gravitational forces exerted by the sun and
the moon on the Earth induce latitudinal and longitudinal
strains within the solid matrix and cause deformations with
two dominant periods: diurnal and semi-diurnal. The tidal
gravitational potential can be resolved into a finite set of
tidal components described as harmonics, which are sinu-
soidal functions of given amplitude and frequency
(Doodson and Warburg 1941; Cutillo and Bredehoeft
2011). Five main components account for about 95% of the
tidal potential: the M2 and N2 semidiurnal lunar tides, the
S2 semidiurnal solar tide, the O1 diurnal lunar tide, and the
K1 diurnal lunar-solar tide.
Seasonal or climatic variations, anthropogenic activities
and tidal forces induce hydraulic pressure changes in
geological formations. The amplitude of the pressure
response depends on the poroelastic response of the aquifer
matrix. Pressure signal can therefore be analysed to
determine hydrogeological properties, such as specific
storage, effective porosity and hydraulic conductivity. The
models used in this work are based on Terzaghi’s (1936)
effective stress concept, which assumes a constant total
stress distributed between grains and fluid stress. Brede-
hoeft (1967) related tidal strain to specific storage:
Ss ¼Dej jDhj j ; ð11Þ
where Ss is the specific storage [m-1], |De| is the amplitude
of volumetric strain fluctuation fixed at 2 9 10-8 for the
M2 tide (Melchior 1978), and |Dh| is the amplitude of rel-
ative pressure head fluctuations [m].
Jacob‘s (1940) formula was used to compute the
porosity:
x ¼ EWSsB
qf g; ð12Þ
where x correspond to the porosity [-], EW is the stiffness
modulus of water, equal to 2.05 GPa, Ss is the specific stor-
age [m-1], B is the barometric efficiency [-], which reflects
the elastic response of the system, qf is the fluid density, andg is the gravity acceleration equal to 9.81 m s-2.
Hydraulic conductivity was estimated with formulations
using the M2 harmonic amplitude and phase shift (Boldt-
Leppin and Hendry 2003; Timms and Acworth 2005),
measured at two depths, z1 and z2 [m]:
KAmpt fM2
ð Þ ¼ Ss fM2ð Þ z1 � z2ð Þ2
fM2ð Þ�1
lnAz1 fM2
ð ÞAz2 fM2
ð Þ
� �� ��2
ð13Þ
KAmpt fM2
ð Þ ¼ Ss fM2ð Þ z1 � z2ð Þ2
fM2ð Þ�1
lnAz1 fM2
ð ÞAz2 fM2
ð Þ
� �� ��2
; ð14Þ
where KAmpt is the ‘‘amplitude effective hydraulic conduc-
tivity’’, Az1 and Az2 [kPa], are the M2 earth tide amplitude
associated to the sensors, Ss [m-1] is the arithmetic mean of
the effective specific storage coefficients obtained indi-
vidually for the two sensors, fM2 [s-1] is the frequency of
the M2 earth tide equal to 2.236 9 10-5 Hz, KDut [m s-1]
is the ‘‘phase effective hydraulic conductivity’’, and Du[rad] is the spectral phase shift between the sensors.
Spectral analysis of BDB-1 borehole pressure dataset
was performed using the Multi-Statistical Analysis Tool
(MuSTAT v1), jointly developed by the Institut de
Table 2 Plausibility ranges set in nSIGHTS for fitted parameters
Fitted parameter Plausibility range
K [m s-1]
Interval 1 10-13–10-8
Interval 2 to 7 10-13–10-11
Ss [m-1] 10-8–10-4
Flow dimension [-] 1–3.5
Skin thickness [cm] 0.5–30
External boundary radius [m] 0–5
K stands for hydraulic conductivity and Ss for specific storage. Skin
zone conductivity ranges were set one order of magnitude higher
compared to intact rock
90 C. Yu et al.
Radioprotection et de Surete Nucleaire and the Institut
National Polytechnique de Toulouse (Fatmi et al. 2008;
Ababou et al. 2012; Bailly et al. 2014). Consisting in a
Python code associated with toolboxes programmed in
Matlab, the package provides automatic features: (a) pre-
processing of time series, that enables the detection of time
gaps and spurious values, as well as data reconstruction by
autoregressive first order process; (b) processing of a single
time series; (c) cross-analysis of two time series.
5 Results at various scales of investigation
5.1 Sub-millimeter to centimeter scale
5.1.1 Petrophysical parameters
The petrophysical parameters necessary for the computa-
tion of intrinsic permeability are presented in Fig. 5 as a
function of distance along BDB-1 borehole.
The mean water accessible porosity is 13.0% in the
Opalinus Clay, with a lower average porosity of 12.0% in
the sandy facies compared to the shaly facies, which
exhibit a mean porosity of 13.5%. These values are lower
than the mean value of 18% suggested by previous studies
performed at the Mont Terri tunnel level. The Passwang
Formation presents slightly lower porosity values ranging
between 8.1 and 14.6% with a mean value of 12.2%. The
Hauptrogenstein is characterised by the lowest porosity
with a mean value of 3.9%.
Grain densities obtained by helium pycnometry have a
mean value of 2.74 g cm-3 in the Opalinus Clay overlying
formations and of 2.72 g cm-3 in the argillaceous layer.
The lowest grain densities are found in the bituminous
Rietheim Member of the Staffelegg Formation (see
Fig. 1a), ranging between 2.3 and 2.4 g cm-3. These low
values are probably linked to the presence of organic
matter.
The Passwang Formation, which directly overlays the
Opalinus Clay, does not reveal clear petrophysical dis-
crepancies with the clay formation except for the specific
surface area. This parameter has an average value of
13 m2 g-1 in the carbonated section of the borehole and
shows significant fluctuations linked to the marly compo-
sition of the Passwang Formation. A higher mean value of
29 m2 g-1 characterises the Opalinus Clay.
The Opalinus Clay is also characterised by a low pore
size. Analyses of nitrogen adsorption and desorption iso-
therms show that 70 to 93% of the connected porous net-
work is constituted of mesopores (pore diameter between 2
and 50 nm), with a mean size of 13 nm. Calculation of the
half-pore size from petrophysical parameters, following
Fig. 5 Petrophysical parameters acquired along BDB-1 borehole: a Water accessible porosity acquired by oven-drying at 105 �C; b Specific
surface area obtained by BJH and BET methods; c Grain density estimated by helium pycnometry on oven dried samples
Mont Terri, paper #4: hydraulic parameters in Opalinus Clay 91
Eq. (5), gives mean pore sizes in the range of 3.1 to
7.3 nm.
Ranging between 1.3 and 5.4 (Horseman et al. 1996),
the cementation factor was estimated to be close to 2 for
compacted and deeply buried sediments (Ullman and Aller
1982; Tremosa 2010). Van Loon et al. (2003) related the
effective diffusion coefficient of tritium measured in the
Opalinus Clay to its porosity using a cementation factor of
2.5. An attempt was made to compute cementation factors
from conductivity values obtained by borehole logging in
BDB-1 and water-accessible porosity determined at labo-
ratory scale. No real conductivity of formation fluid was
acquired in the Opalinus Clay, as this part of the borehole
was drilled with air. Therefore, fluid conductivity values
were estimated based on chlorinity data acquired on BDB-
1 core samples (not detailed in this paper). Low values of
cementation factors are thus obtained and range between
0.9 and 1.7.
5.1.2 Intrinsic permeability and hydraulic conductivity
The intrinsic permeability profiles (Fig. 6a) show a low
vertical variability through the Opalinus Clay, where it
ranges between 1.8 9 10-21 and 6.1 9 10-20 m2 if a
cementation factor varying between 2 and 3 is taken. For a
cementation factor of 2.5, the mean intrinsic permeability
is 7.7 9 10-21 m2 for the Opalinus Clay shaly facies and
7.9 9 10-21 m2 for its sandy facies. These values are in
good agreement with the range of 1 9 10-21 and
6 9 10-20 m2 obtained by gas injection experiments per-
formed at the Mont Terri laboratory (Marschall et al.
2005). Based on the same cementation factor, difference
can be seen in the carbonate-rich sandy facies, where
values are about three times higher than in the shaly and
the sandy facies. With a higher exponent m = 3, the
resulting intrinsic permeability has a mean value of
7.6 9 10-21 m2 and no clear distinction arises between the
different facies. The intrinsic permeability values com-
puted in the Passwang Formation and the Staffelegg For-
mation are much more heterogeneous and vary between
1.5 9 10-21 and 5.8 9 10-20 m2.
The corresponding hydraulic conductivity profiles are
presented in Fig. 6b and show similar trends compared
with the intrinsic permeability profiles. The hydraulic
conductivity obtained for the Opalinus Clay ranges
between 1.9 9 10-14 and 5.8 9 10-13 m s-1 for a
cementation factor varying between 2 and 3. For a
cementation factor of 2.5, the formation is characterised by
a mean hydraulic conductivity of 8.3 9 10-14 m s-1. No
clear discrepancy between the shaly facies and the sandy
Fig. 6 a Intrinsic permeability profile and b hydraulic conductivity
profile computed across the Opalinus Clay (OPA) and the Passwang
Formation for cementation factor (m) of 2, 2.5 and 3. Square symbols
represent values for variable m computed based on conductivity
logging measurements across the Opalinus Clay
92 C. Yu et al.
facies is revealed, with respective mean values of
7.3 9 10-14 and 6.9 9 10-14 m s-1. These values are
consistent with the range of 2 9 10-14–1 9 10-12 m s-1
reported in previous studies (Bossart and Thury 2008). The
Passwang Formation and the Staffelegg Formation present
a various range of hydraulic conductivities between
1.6 9 10-14 and 6.1 9 10-13 m s-1.
The computation of intrinsic permeability using variable
cementation factors in the Opalinus Clay gives higher
values in the range of 4.0 9 10-20 to 1.9 9 10-19 m2,
corresponding to hydraulic conductivity values in the range
of 4.1 9 10-13–1.7 9 10-12 m s-1.
5.2 Decimeter to meter scale: in situ hydraulic tests
results
Pore pressure should be fully recovered from artificial
disturbance induced by the installation procedure (e.g.,
drilling, logging, equipment installation) before starting a
hydraulic test. Steady state was considered to be reached
when the tidal components were detected on all pore
pressure time series acquired in BDB-1 borehole, which
indicate that the system is fully pressurised and saturated
(see Sect. 5.3.1).
The observed compressibility of the test zone (Ctz) was
deduced from pulse tests and computed according to:
Ctz ¼1
Vtz
dV
dP; ð14Þ
where Vtz [m3] is the shut-in volume, dV [m3] is the
withdrawn volume and dP [Pa] is the pressure variation.
Test zone compressibility in BDB-1 borehole varies
9.1 9 10-10 and 2.4 9 10-9 Pa-1 (Fig. 7), approximately
up to a factor of 5 larger than water compressibility, which
is equal to 4.8 9 10-10 Pa-1 at 10 �C (Kell 1975). The
discrepancy can be attributed to the mechanical compliance
of the equipment.
Semi-logarithmic plots presented in Fig. 8 give a qual-
itative comparison of the hydraulic behaviours character-
ising the different tested intervals. Degree of pore pressure
dissipation (U) and normalised drawdown pressure (Unorm)
are respectively defined by the following equations:
U ¼ Ut � U0
Umin � U0
ð15Þ
Unorm ¼ Ut � Umin
U0 � Umin
; ð16Þ
where Ut [kPa] is the pore pressure at time t, U0 [kPa] is the
hydrostatic pore pressure in situ and Umin [kPa] is the pore
pressure reached after pulse application or at the end of the
pumping phase.
Discrepancies in the degree of dissipation can be
observed between tests performed on a same interval
(Fig. 8a). Constant rate withdrawal tests were carried out
using the same flow rate of 0.3 g h-1 for different dura-
tions. To compare the evolution of pore pressures in the
measuring intervals during pumping phase, Pmin was taken
to correspond to the shortest pumping duration in the cal-
culation of Unorm. If specific storage is assumed homoge-
neous through the Opalinus Clay, the order from left to
right on Fig. 8b gives an indication of decreasing
permeability.
The application of a composite model, which takes into
account a damaged skin zone, was required for most of the
test numerical interpretations. Taking as an example the
first pulse test carried out on BDB-1 Interval 2, Fig. 9
shows a comparison of the residuals (measured value
minus simulated value) to that of a normal distribution,
using a homogeneous model and a composite one. The
homogeneous model appears to be unsatisfactory because
the residuals are not normally distributed, which indicates
the presence of a systematic error.
Pulse tests and constant rate pumping tests results are
respectively compiled in Table 3. Pulse testing revealed
the highest hydraulic conductivity values in the Staffelegg
Formation (Interval 1, see Fig. 2b) with best fit values
ranging from 2.1 9 10-10 to 5.9 9 10-10 m s-1. Located
in the basal shaly facies of Opalinus Clay (Interval 2), the
bottom part of the main fault zone is characterised by
conductivity values from 3.1 9 10-12 to
7.3 9 10-12 m s-1 and do not differ from the upper shaly
facies represented by Interval 4 and 5 (Fig. 10), whose
best estimates are up to 4.2 9 10-12 m s-1. The lowest
values are found in the sandy facies (Interval 6, best fit
values up to 2.7 9 10-13 m s-1), and the carbonate-rich
sandy facies (Interval 3, best fit values up to
5.1 9 10-13 m s-1). The basal part of the Passwang
Fig. 7 System compressibility computed from pulse testing in BDB-
1 borehole. Dashed line represents the water compressibility at 10 �C.The outlier in the lower part of the borehole is due to a very low
withdrawn volume
Mont Terri, paper #4: hydraulic parameters in Opalinus Clay 93
Formation, represented by Interval 7, shows similar
hydraulic conductivity values to Opalinus Clay
(5.8 9 10-13–1.4 9 10-12 m s-1).
The analyses results of the constant flowrate withdrawal
tests are quite consistent with those obtained from pulse
tests. Indeed, a similar trend can be observed with slightly
Fig. 9 Example of residual plots for the optimization of Interval 2 (Opalinus Clay shaly facies) pulse sequence fit to the Cartesian pressure
response using a an homogeneous model and b a composite model with skin
Fig. 8 Comparison of the different tests performed on BDB-1
borehole: a degree of dissipation associated to the recovery phases
of pulse withdrawal tests; b normalised pressure drawdown during
constant rate withdrawal tests and c degree of dissipation following
the end of the withdrawal phase
94 C. Yu et al.
Table 3 Parameter estimates from BDB-1 borehole pulse withdrawal tests and constant rate (CR) withdrawal tests (K [m s-1]: hydraulic
conductivity; Ss [m-1]: specific storage; n: flow dimension; ts [cm]: skin thickness)
Test Interval Ts
[cm]
K [m s-1] Ss [m-1] n
Formation Skin Formation Skin
Range Best fit Best fit Range Best fit Best fit Range Best
fit
Pulse
C1–1 I1 – 1 9 10-10–3.5 9 10-10 2.1 9 10-10 – 6 9 10-9–
6.3 9 10-81.4 9 10-8 – 1.9–2.7 2.2
C1–2 I1 – 1 9 10-11–1 9 10-7 4.2 9 10-10 – 1.4 9 10-6 – 2.0
C1–3 I1 – 1 9 10-11–1 9 10-7 5.6 9 10-10 – 6.3 9 10-8 – 2.4
C1–6 I1 – 3 9 10-11–1 9 10-8 5.9 9 10-9 – 8.3 9 10-7 – 2.0
C2–1 I2 0.5 2 9 10-12–3 9 10-11 3.1 9 10-12 7.8 9 10-12 1 9 10-7–
3 9 10-55.2 9 10-6 4.3 9 10-5 1.8–3.0 2.8
C2–2 I2 0.5 2 9 10-12–1 9 10-10 7.3 9 10-12 1.0 9 10-11 1 9 10-7–
2 9 10-53.0 9 10-6 4.7 9 10-5 1.4–2.9 2.0
C3–1 I3 0.5 1 9 10-13–3 9 10-12 5.1 9 10-13 1.6 9 10-12 5 9 10-7–
3 9 10-53.7 9 10-6 1.2 9 10-5 1.4–3.1 2.1
C3–2 I3 0.5 2 9 10-13–2 9 10-12 4.9 9 10-13 1.6 9 10-12 2 9 10-6–
3 9 10-51.1 9 10-5 1.5 9 10-5 1.4–3.4 2.5
C4–1 I4 0.5 1 9 10-12–9 9 10-12 2.3 9 10-12 5.7 9 10-12 2 9 10-6–
1 9 10-56.4 9 10-6 5.5 9 10-5 1.7–3 2.3
C4–2 I4 2.0 7 9 10-13–1 9 10-11 4.2 9 10-12 2.7 9 10-11 1 9 10-6–
2 9 10-52.2 9 10-6 9.7 9 10-6 1.5–3 2.0
C5–1 I5 0.5 4 9 10-13–4 9 10-12 1.6 9 10-12 1.4 9 10-12 3 9 10-7–
8 9 10-61.0 9 10-6 2.6 9 10-5 1.8–2.9 1.9
C5–2 I5 0.5 4 9 10-13–3 9 10-12 1.0 9 10-12 2.7 9 10-12 1 9 10-6–
3 9 10-58.5 9 10-6 4.7 9 10-5 1–3 2.5
C6–1 I6 1.5 8 9 10-14–8 9 10-13 1.9 9 10-13 1.4 9 10-11 8 9 10-7–
1 9 10-56.6 9 10-6 6.6 9 10-6 1.7–3 2.6
C6–2 I6 0.5 2 9 10-13–6 9 10-13 2.7 9 10-13 5.4 9 10-12 1 9 10-6–
2 9 10-51.7 9 10-5 2.9 9 10-5 1.7–3 2.8
C7–1 I7 0.5 3 9 10-13–4.5 9 10-12 5.8 9 10-13 3.7 9 10-13 4 9 10-7–
2 9 10-53.7 9 10-6 1.9 9 10-6 1.9–3.5 3.0
C7–2 I7 0.5 4 9 10-13–2 9 10-12 1.4 9 10-12 8.6 9 10-12 10-9–
2 9 10-51.2 9 10-6 9.4 9 10-7 2.1–2.6 2.3
CR
C1–7 I1 4.3 1 9 10-10–1 9 10-9 5.0 9 10-10 5.7 9 10-9 1 9 10-8–
1 9 10-48.2 9 10-6 6.2 9 10-5 2.0–3.0 2.1
C2–2 I2 14.2 4 9 10-13–8 9 10-11 3.9 9 10-12 3.5 9 10-11 1.2 9 10-6 9.0 9 10-5 1.4–2.7 1.95
C3–3 I3 0.7 1 9 10-13–2 9 10-12 9.9 9 10-13 1.6 9 10-12 3 9 10-8–
6 9 10-51.5 9 10-5 4.9 9 10-5 1.5–3.0 1.9
C4–3 I4 1.4 4 9 10-14–5 9 10-12 2.4 9 10-12 3.0 9 10-12 4 9 10-8–
3 9 10-41.2 9 10-5 4.0 9 10-5 1.9–3.0 2.1
C5–3 I5 1.8 7 9 10-14–9 9 10-12 8.1 9 10-13 1.5 9 10-11 1 9 10-7–
3 9 10-58.9 9 10-5 2.4 9 10-5 1.9–3.0 2.3
C6–3 I6 0.5 1 9 10-14–4 9 10-12 2.2 9 10-13 1.1 9 10-12 1 9 10-7–
2 9 10-57.7 9 10-6 9.9 9 10-5 1.5–2.9 2.5
C7–3 I7 0.6 1 9 10-13–1 9 10-12 4.4 9 10-13 8.2 9 10-13 3 9 10-8–
4 9 10-68.5 9 10-6 2.3 9 10-5 2.1–3.0 2.7
Shaded cells represent unrealistically wide range of uncertainties
Mont Terri, paper #4: hydraulic parameters in Opalinus Clay 95
higher permeability values in the shaly facies than in the
sandy facies of Opalinus Clay.
Specific storage and flow dimension estimates are highly
variable. One issue with single well hydraulic testing is that
the volume of tested rock is limited to the immediate
vicinity of the well.
5.3 Hectometer scale: tidal analysis
5.3.1 Tidal identification in BDB-1 pore pressure series
Detection of tidal components was performed on the pore
pressure time series monitored by the sensors placed in
BDB-1 borehole, with an acquisition time step set at
15 min. The four largest amplitude tidal components, O1,
K1, S2 and M2 appear on all processed signals at the exact
expected frequencies for time series between September
1st 2014 and March 10th 2015 (Fig. 11).
The form ratio is defined as the sum of the two main
diurnal component amplitudes, K1 and O1, divided by the
sum of the two main semi-diurnal component amplitudes,
M2 and S2 (Wiegel 1964). Tidal deformation through the
Opalinus Clay at Mont Terri is characterised by a form
ratio varying between 0.84 and 1.04, which indicates a
mixed, mainly semi-diurnal tide (Table 4). The maximum
value is found in the interval located in the Passwang
Formation, for which the diurnal components have slightly
higher amplitudes than the semi-diurnal ones. Except for
this interval, the M2 tide presents the highest amplitude
among the four major tides.
5.3.2 Hydraulic parameters computation
The results of specific storage coefficient computation are
given in Table 5. Specific storage values are ranging
between 1.1 9 10-6 and 1.6 9 10-6 m-1 in the Opalinus
Clay and are higher for the adjacent formations
(2.4 9 10-6 m-1 for the Lower Dogger limestone and
3.1 9 10-6 m-1 for the Staffelegg Formation). These
estimates are consistent with the range given in the liter-
ature, deduced from in situ packer tests and permeameter
Fig. 10 a Simulation of a pulse test performed on BDB-1 Interval 5 located in the upper shaly facies of Opalinus Clay and b associated Ramey
A plot with best fit parameters. Results of 200 perturbation analyses and their confidence regions (c and d)
Fig. 11 Estimated Root Mean Square spectrum of pore pressure time
series measured in BDB-1 borehole between 01/09/2014 and 10/03/
2015. The following tides are observable: principal lunar semidiurnal
tide M2 (2.236 9 10-5 Hz) and solar semidiurnal tide S2(2.315 9 10-5 Hz), lunar diurnal tides K1 (1.161 9 10-5 Hz) and
O1 (1.076 9 10-5 Hz), and the solar diurnal components S1(1.157 9 10-5 Hz) and P1 (1.154 9 10-5 Hz)
c
96 C. Yu et al.
Mont Terri, paper #4: hydraulic parameters in Opalinus Clay 97
tests for the Opalinus Clay shaly facies: between 1 9 10-7
and 1 9 10-4 m-1, with a best estimate at 2 9 10-6 m-1
(Bossart and Thury 2008).
Effective dynamic porosity values obtained using the
M2 tide (Table 6) are globally in well agreement with those
obtained from petrophysical measurements. Indeed,
coherent values between 8 and 24% are obtained by cross-
analyses of measuring intervals located in the Opalinus
Clay. Statistical analysis carried out in previous studies on
Mont Terri samples (Fatmi 2009; Bailly and Matray 2015)
revealed very low range values between 1 and 4% at the
tunnel level. These unexplained low values could be
Table 4 Amplitudes of the tidal components with associated frequencies observed on BDB-1 pore pressure time series between 01/09/2014 and
10/03/2015
Formation/associated chamber Amplitude on the RMS spectrum [bars] Form ratio
O1
(1.076 9 10-5 Hz)
K1
(1.161 9 10-5 Hz)
S2(2.315 9 10-5 Hz)
M2
(2.236 9 10-5 Hz)
Staffelegg formation/I1 5.886 9 10-4 6.326 9 10-4 3.606 9 10-4 8.353 9 10-4 1.02
OPA-shaly facies/I2 1.054 9 10-3 1.230 9 10-3 6.848 9 10-4 1.696 9 10-3 0.96
OPA-shaly facies/I2–3 1.041 9 10-3 1.192 9 10-3 7.390 9 10-4 1.823 9 10-3 0.87
OPA-carbonate-rich facies/I3 7.905 9 10-4 9.553 9 10-4 5.014 9 10-4 1.255 9 10-3 0.99
OPA-shaly facies/I4 9.560 9 10-4 1.133 9 10-3 6.838 9 10-4 1.701 9 10-3 0.88
OPA-shaly facies/I5 8.591 9 10-4 1.084 9 10-4 6.546 9 10-4 1.670 9 10-3 0.84
OPA-sandy facies/I6 8.637 9 10-4 1.205 9 10-3 5.329 9 10-4 1.278 9 10-3 1.04
Passwang formation/I7 5.200 9 10-4 7.206 9 10-4 2.825 9 10-4 6.360 9 10-4 1.35
Table 5 Specific storage coefficients (Ss) estimated from absolute pore pressure signals for BDB-1 borehole measuring intervals with corre-
sponding formations and amplitudes of pressure head fluctuations Dh
Formation Chamber Dh [bar] Dh [m] Ss [m-1]
Upper toarcian-staffelegg formation I1 8.353 9 10-4 8.52 9 10-3 2.4 9 10-6
Upper toarcian/lower aalenian-opalinus clay–shaly facies I2 1.696 9 10-3 1.73 9 10-2 1.2 9 10-6
Upper toarcian/lower aalenian-opalinus clay–shaly facies I2–3 1.823 9 10-3 1.86 9 10-2 1.1 9 10-6
Lower aalenian-opalinus clay–carbonate-rich facies I3 1.255 9 10-3 1.28 9 10-2 1.6 9 10-6
Lower aalenian opalinus clay–shaly facies I4 1.701 9 10-3 1.73 9 10-2 1.2 9 10-6
Middle aalenian-opalinus clay–shaly facies I5 1.670 9 10-3 1.70 9 10-2 1.2 9 10-6
Upper aalenian-opalinus clay–sandy facies I6 1.278 9 10-3 1.32 9 10-2 1.5 9 10-6
Upper aalenian-passwang formation I7 6.360 9 10-4 6.49 9 10-3 3.1 9 10-6
Table 6 Spectral coherence function (Coh), arithmetic mean of the specific storativity coefficient (~Ss), amplitude of the pore pressure signal 1
(Az1), and of the pore pressure signal 2 (Az2), vertical effective amplitude hydraulic conductivity ( ~KAmpt ) and vertical effective phase hydraulic
conductivity ( ~KDut ), effective dynamic porosity (x) obtained for the M2 earth tide for different couples of sensors in BDB-1 borehole
Chamber Coh ~Ss Az1 Az2 Du ~KAmpt
~KDuv
B x xwater loss
[-] [m-1] [bar] [bar] [rad] [m s-1] [m s-1] [-] [-] [-]
I1 vs. I2 0.9985 1.8 9 10-6 8.35 9 10-4 1.70 9 10-3 -0.18220 4.7 9 10-8 7.2 9 10-7 0.2520 0.09 0.18
I2 vs. I2–3 0.9992 1.1 9 10-6 1.70 9 10-3 1.82 9 10-3 0.03573 2.5 9 10-6 1.0 9 10-5 1.0350 0.24 0.15
I2–3 vs. I3 0.9986 1.3 9 10-6 1.82 9 10-3 1.26 9 10-3 0.07658 1.4 9 10-7 3.3 9 10-6 0.3949 0.11 0.13
I3 vs. I4 0.9977 1.4 9 10-6 1.26 9 10-3 1.70 9 10-3 -0.06768 2.9 9 10-7 5.8 9 10-6 4.6810 1.33 0.12
I4 vs. I5 0.9930 1.2 9 10-6 1.70 9 10-3 1.67 9 10-3 0.02158 5.7 9 10-5 4.1 9 10-6 0.4758 0.12 0.14
I5 vs. I6 0.9965 1.4 9 10-6 1.67 9 10-3 1.28 9 10-3 -0.05037 6.4 9 10-7 1.8 9 10-5 0.2889 0.08 0.13
I6 vs. I7 0.9965 2.3 9 10-6 1.28 9 10-3 6.36 9 10-3 0.50810 3.9 9 10-8 7.3 9 10-8 1.6290 0.79 0.13
Mean water-loss porosity (xwater loss) is given for comparison purposes
Shaded cells indicate spurious values
98 C. Yu et al.
related to the hydraulically disturbed state of the studied
area and desaturation phenomena.
Hydraulic conductivity values obtained in the saturated
part of the claystone by cross-analysis (Table 6) are much
higher than those obtained by other techniques. Indeed,
high conductivities ranging between 5.7 9 10-5 and
1.4 9 10-7 m s-1 are found in the Opalinus Clay. These
values are 6 to 8 orders of magnitude higher than the range
expected from literature data, suggesting that the method is
not appropriate for this formation. Discrepancies up to
three orders of magnitude between laboratory hydraulic
conductivity results and tidal analysis results were also
reported by Boldt-Leppin and Hendry (2003) who studied
the King site claystone formation (Canada). These dis-
crepancies were explained by scale factor effects and the
presence of fractured area.
Bailly and Matray (2015) performed statistical analysis
on pore pressure time series acquired in the BCD-3 bore-
hole located at the Mont Terri tunnel level. They obtained
hydraulic conductivities ranging between 1.9 9 10-10 and
7.5 9 10-11 m s-1 in the unsaturated part of the Opalinus
Clay by applying the same method on the S1 solar diurnal
tide. The M2 tide was not found in the studied pore pressure
time series due to suction conditions associated to the rock
laboratory level. The study also suggested that the struc-
tures observed in this borehole were hydraulically con-
ductive, meaning that the Opalinus Clay true permeability
should be even lower than the range given by tidal analysis.
6 Discussion
6.1 Comparability of laboratory tests and in situ
tests results
Reliable estimates of permeability and specific storage that
describe the bulk hydraulic behaviour are needed for the
evaluation of radionuclide transport in geological forma-
tions. Linking the results of laboratory tests to bulk char-
acteristics at the regional scale is not straightforward and
the meaning of measured values has to be interpreted.
Sedimentary rocks are generally associated with aniso-
tropic properties such as permeability, diffusion coefficient
and mechanical features. In the Opalinus Clay, which is an
overconsolidated clay, a moderate permeability anisotropy
ratio of 5.5 was estimated based on laboratory permeameter
tests (Munoz et al. 2003; Croise et al. 2004; Fernandez-
Garcia et al. 2007).
The petrophysical model is based on a conceptual par-
allel plane geometry which would be associated to a flow
orientation parallel to bedding planes. Since BDB-1 bore-
hole was drilled perpendicular to bedding plane, the main
solicited direction for fluid flow during hydraulic testing is
also parallel to stratification. For its part, tidal analysis is
mainly based on gravitational forces that propagate radially
from the center of the Earth and should result, given the
setting of the Mont Terri anticline, in composite values of
parallel and perpendicular to bedding permeabilities.
Although the petrophysical model may be unsuited to
carbonated formations, calculation was also performed on
the Passwang Formation and the Staffelegg Formation,
which shows similar petrophysical parameters. Another
questionable point is the use of a constant value for the
Archie’s exponent since this parameter depends on the
nature of the porous medium. Consequently, adapted val-
ues should be taken in the future according to the evolution
of rock facies along the stratigraphic sequence. Conduc-
tivities values obtained in BDB-1 with variable cementa-
tion factor (Fig. 12a) are only indicative and not quality-
assured, given the uncertainties linked to data acquisition.
Indeed, the Opalinus Clay was in the air-drilled section of
the borehole, giving constraints for in situ determination of
cementation factor.
Fitting the cementation factor by comparing petro-
physical results and estimates from hydraulic tests can be
debatable. Indeed, the volume of solicited rock is higher in
the latter case and takes greater account of formation
heterogeneities and local potentially open fractures. This
point is clearly illustrated by the discrepancies observed for
the Staffelegg Formation, in which many fractures were
evidenced by drillcore mapping. Indeed, petrophysical
measurements on centimetre-scale samples do not take into
account these hydraulically conductive structures and
underestimate the values of bulk properties.
Archie’s law is rigorously an empirical relationship that
links the electrical resistivity of saturated clay-free rocks
and their porosity. However, an analogy can be made
between the electrical potential and the concentration. It
has been shown that effective diffusion coefficient could be
predicted by this relationship in a variety of clays and
shales with a cementation factor ranging between 2 and 3
(Boving and Grathwohl 2001; Van Loon et al. 2003;
Mazurek et al. 2009). Best fit values of hydraulic con-
ductivity obtained from hydraulic testing are generally
higher that those computed with the petrophysical law
(Fig. 12a). Hydraulic conductivities higher than
10-12 m s-1 found in the Opalinus Clay shaly facies would
be associated to illogical values of cementation factor
inferior to 1.3, which was given for clean unconsolidated
sand packs by Archie (1942).
Whether it be for pulse or constant withdrawal tests, the
numerical interpretation of hydraulic tests suggests rather
wide and unrealistic ranges of uncertainties for hydraulic
conductivity and specific storage. Covering several orders
of magnitude and not tightly around the best estimates
(Table 3), these uncertainties are probably linked to the
Mont Terri, paper #4: hydraulic parameters in Opalinus Clay 99
large number of fitted parameters. Tidal analysis may be
more representative than single well hydraulic testing for
specific storage estimation (Fig. 12b), since the tidal
deformation is applied to the entire rockmass. The highest
values for specific storage obtained from pulse testing
should be taken with caution since the sensitivity to this
parameter is low for this kind of test (Cooper et al. 1967).
6.2 Consistency with previous results
Numerous in situ and laboratory investigations have been
carried out at the Mont Terri rock laboratory to charac-
terize the hydraulic properties of the Opalinus Clay. Lab-
oratory permeameter tests revealed conductivity values
ranging from 6 to 12 9 10-14 m s-1 with high associated
storage coefficient of 4.8 9 10-4 m-1 (Croise et al. 2004).
Figure 13 shows a compilation of hydraulic conductivity
results obtained from packer tests (pulse, constant head and
constant rate) performed previously at the Mont Terri site
(Lavanchy and Mettier 2012), along with data collected in
BDB-1 borehole. Tests were mainly performed in bore-
holes oblique or normal to bedding drilled in area unaf-
fected by the excavation damaged zone of the tunnel.
Previous permeability values measured at the rock labo-
ratory level range from 1.5 9 10-14 to 1.1 9 10-9 m s-1
with 55% of the values in the order of 10-13 m s-1. The
high values above 1.1•10-10 m s-1 of the shaly facies
from previous studies might be affected by the excavation
damaged zone (EDZ) and are not quality assured. The best
fit values obtained from BDB-1 hydraulic testing fall vir-
tually in the expected range with higher values in the order
of 10-12 m s-1 characterising the Opalinus Clay shaly
facies.
Specific storage coefficients obtained by tidal analysis
are rather homogeneous within the Opalinus Clay with
values in the order of 10-6 m-1, which are comparable to
the range of 2 9 10-6 to 5 9 10-6 m-1 found by Bailly
and Matray (2015).
No significant correlation between the hydraulic con-
ductivity and the different lithological facies was high-
lighted by Croise et al. (2004), Nussbaum and Bossart
(2004) and Lavanchy and Mettier (2012) due to a lack of
data from the sandy facies. Although best fit values
obtained from BDB-1 borehole indicate higher values in
the shaly facies, uncertainty ranges make it difficult to
conclude on a possible contrast. Numerical simulations
show that sandstone lenses embedded in clay rich strata do
not compromise the barrier function of the Opalinus Clay
since low hydraulic conductivity values characterise the
entire formation. Furthermore, Opalinus Clay sandy layers
are better cemented and display lower porosities (Fig. 5a).
Microscopic observations in the sandy facies revealed
precipitation of authigenic quartz, carbonates and kaolinite
(Peters et al. 2011). On the other hand, porosity values
measured in BDB-1 borehole are globally lower than those
obtained at the rock laboratory tunnel level and may reflect
Fig. 12 Comparison of results obtained by petrophysical analysis, in situ hydraulic testing and tidal spectral analysis performed on BDB-1
borehole: a hydraulic conductivity b specific storage
100 C. Yu et al.
the deconfinement and relaxation of stresses occurring at
the latter location.
The Main Fault that intersects the laboratory does not
impact the barrier function of the Opalinus Clay. Indeed,
the sealing of fault planes by calcite shear fibres and clay
minerals induce small effect of tectonic deformation on the
hydraulic properties of the Opalinus Clay (Nussbaum et al.
2011). This observation is supported by the consistency
between the hydraulic tests performed in the intact shaly
facies and those carried out in the interval crossing the fault
zone. Similarly, no contrast can be identified on the dif-
ferent profiles obtained with the petrophysical model.
7 Conclusions
The deep borehole (DB) experiment enabled the acquisi-
tion of data in a fresh borehole penetrating the entire
hydraulically undisturbed Opalinus Clay at Mont Terri.
Therefore, the presented results are unique, because other
hydraulic data at Mont Terri are or might be influenced by
tunneling and experimental activities. Three methods with
different investigation volumes were carried out and
compared.
A model that links intrinsic permeability to petrophys-
ical parameters gives intrinsic permeability values ranging
between 2 9 10-21 and 6 9 10-20 m2 for a cementation
factor varying between 2 and 3, corresponding to hydraulic
conductivities between 2 9 10-14 and 6 9 10-13 m s-1.
Tidal analysis revealed itself not to be an appropriate
method to compute hydraulic conductivity in our study,
giving values overestimated of several orders of
magnitudes. However, this approach gives reasonable
values for specific storage and effective porosity. As a third
method, in situ hydraulic testing was performed using the
multipacker system installed in BDB-1 borehole. Hydraulic
conductivity values obtained by numerical inversion from
pulse tests are consistent with those deduced from constant
rate withdrawal tests, and suggest a slight vertical vari-
ability across the formation in the range of 1 9 10-13 to
7 9 10-12 m s-1, possibly due to local variations of the
matrix structure, composition and cementation, or the
presence of fractures. In conclusion, the hydraulic con-
ductivity values of the deep borehole (DB) experiment
agree well with previous hydraulic testing results per-
formed in the hydraulically disturbed Opalinus Clay
around the Mont Terri rock laboratory. Therefore, future
hydraulic testing in the laboratory outside the excavated
damaged zone can be rated as comparable to undisturbed
conditions. However, results obtained in BDB-1 borehole
show higher values (in the order of 10-12 m s-1) for the
Opalinus Clay shaly facies than its sandy facies (in the
order of 10-13 m s-1), which is consistent with previous
microscopic observations (Peters et al. 2011). Further
laboratory experiments using Hassler cells will be per-
formed to characterise the Opalinus Clay permeability
anisotropy in the future.
Petrophysical analysis of drillcores and time-series
analyses are complementary to hydraulic testing. These
techniques involve different volumes of investigation. Core
analysis, as well as laboratory permeameter tests, give the
homogeneous matrix hydraulic properties but do not
account for larger scale heterogeneities such as sedimen-
tary and tectonic features. Moreover, analyses on core
Fig. 13 Compilation of results from hydraulic borehole packer tests
performed on the Opalinus Clay at the Mont Terri rock laboratory.
The high values of the shaly facies from previous studies might be
affected by the EDZ and are not quality assured (modified from
Lavanchy and Mettier 2012)
Mont Terri, paper #4: hydraulic parameters in Opalinus Clay 101
samples might be influenced by deconfining and alteration
of the core material, thus resulting in biased values.
Therefore, hydraulic testing in a fresh borehole is the
recommended method for determination of hydraulic con-
ductivity in overconsolidated clays. However, the pressure
perturbations e.g., induced by drilling activities have to be
taken into account for design and analyses of hydraulic
testing. The dissipation of drilling and installation of
instrumentation induced pressure pertubations can be
identified by the tidal components in the pore pressure time
series. Our study showed that drilling the BDB-1 borehole
with air as drilling fluid and a saturation with artificial
pore-water was an appropriate choice for our application,
because: (1) no mud-cake was created, (2) no artificial
osmotic effects and borehole convergence were observed
so far, (3) future water sampling can be carried out since
there was no contamination with drilling mud, and (4) we
reached fully undisturbed formation pressures after several
months. The latter was possible to do so in an underground
laboratory experiment, due no time and financial con-
straints, which are limiting factors on drill site for explo-
ration boreholes. Therefore, in clay formations, particular
care should be taken in the choice of drilling method and
drilling fluid as well as borehole instrumentation materials,
in order to obtain accurate hydraulic parameters.
Acknowledgements This study was performed in the framework of
the deep borehole (DB) experiment, financed by six partners of the
International Mont Terri Consortium (swisstopo, NAGRA, BGR,
GRS, NWMO, IRSN). The authors would like to thank Karam Kontar
and Jocelyn Gisiger (Solexperts AG) for their technical support and
realisation of hydraulic testing, as well as Christelle Courbet (IRSN)
and Benoıt Paris (INTERA) for advices on numerical interpretation.
The MuStat v1 package used in this paper is the result of previous
works respectively done by: Alain Mangin (CNRS, Laboratoire
d‘ecologie des hydrosystemes de Moulis), David Labat (Geosciences
Envionnement Toulouse), Rachid Ababou (CNRS/INPT/IMFT),
Hassane Fatmi (PhD at IRSN and CNRS/INPT/IMFT) and David
Bailly (TREES Institute). The constructive and careful reviews of
Prof. Z. Jiang (Queensland University of Technology, Brisbane,
Australia) and Prof. P. Cosenza (University of Poitiers, France)
contributed to improve the initial version of this article and are greatly
acknowledged.
Open Access This article is distributed under the terms of the
Creative Commons Attribution 4.0 International License (http://crea
tivecommons.org/licenses/by/4.0/), which permits unrestricted use,
distribution, and reproduction in any medium, provided you give
appropriate credit to the original author(s) and the source, provide a
link to the Creative Commons license, and indicate if changes were
made.
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